Shaffer Type Annular Blowout Preventer BOP 30" Bore 1000psi Working Pressure

The Shaffer 30"-1000psi Diverter, corresponding to the FH76-7 model, is a critical well control device engineered for high-reliability pressure management in oil and gas drilling operations. Designed in compliance with API Spec 16A and NACE MR 0175/ISO 15156 standards, it integrates annular blowout prevention and diversion capabilities, serving as an indispensable component in surface and sub-surface well control systems.

Well Control & Blowout Prevention: Works in tandem with ram blowout preventers (BOPs) to control wellhead pressure during drilling, workover, and well testing operations, effectively mitigating blowout risks.

Multi-Tool Sealing: Provides reliable sealing for various downhole tools, including kelly pipes, drill pipes, tool joints, drill collars, casings, and cables, as well as sealing the annular space between tubing and casing. It can also fully close the wellhead when no drilling tools are present.

Forced Tripping Operations: Enables forced tripping through 18°/35° non-upset butt-welded joints when equipped with an accumulator buffer.

Diversion System Integration: Functions as a core component of diverter systems when paired with a diversion cross, directing well fluids (such as gas, oil, or drilling mud) away from the rig floor during well kicks.

Temporary Well Sealing: Offers short-term well sealing; for long-term sealing requirements, it must be used in conjunction with ram BOPs.

The diverter operates on hydraulic actuation with supplementary well pressure assistance:

Closing Mechanism: High-pressure hydraulic fluid (rated at 10.5MPa/1,500psi) is injected into the lower closing chamber, driving the piston upward. This forces the spherical packing element to constrict toward the wellbore center, achieving a tight seal around downhole tools or the open bore.

Opening Mechanism: Hydraulic pressure is redirected to the upper opening chamber, pushing the piston downward. The packing element then resets automatically via its inherent rubber elasticity, reopening the wellbore.

Well Pressure Augmentation: After initial sealing, wellbore pressure acts on the upper annular area of the piston cavity, enhancing the sealing tightness and reducing reliance on hydraulic control pressure.

Forced Tripping Procedure: When performing forced tripping, the diverter is closed with 10.5MPa hydraulic pressure, which is then slightly reduced to allow minimal leakage for lubrication. Tripping speed is limited to ≤0.2 m/s when passing tool joints to protect the packing element.

Robust Structural Design: Comprises five main components (lower housing, upper housing, piston, support ring, and packing element) for simplified maintenance and on-site assembly/disassembly.

Enhanced Sealing Performance: Equipped with a spherical packing element featuring alloy steel bow support bars, preventing rubber inversion under high pressure and ensuring reliable sealing even under extreme conditions. The "funnel effect" of the packing element facilitates smooth tool joint entry while improving sealing efficiency.

Wear Resistance & Durability: Incorporates wear-resistant bands on the piston, support ring, and housing to avoid metal-to-metal contact, extending component service life. Lip-type seals minimize friction and leakage, ensuring long-term hydraulic system integrity.

Field Maintainability: The packing element can be replaced on-site—either as a whole (when no tools are in the well) or via cutting (when drilling tools are present)—reducing downtime and operational costs.

Safety Compliance: Rated for a temperature range of -29℃ to 121℃ (metal components) and -18℃ to 121℃ (non-metallic seals), with a hydrostatic test pressure of 10.5MPa/1,500psi and resistance to sulfide stress cracking.

Versatile Compatibility: Compatible with standard hydraulic control systems, accumulators, and diversion accessories, adapting to diverse rig configurations and operational requirements.